wd-a15 single water injector program rev0

Petrofac Malaysia (PM-304) Limited WD-A15 (Loc WI-02/ Slot 9a): Single Water Injector

PML-PR-D-0329

Rev 2

DISTRIBUTION LISTING

Copy Number Document Holder

Master (signed copy)

Document Control Centre (DCC)

Master (electronic)

BMS Administrator

Distribution List

01 Karen Stanley Drilling & Completion Manager

02 Charles Stirrett Drilling Superintendent

03 Edwin Damasena Head of Well Engineering

04 Hamizan Maksari Head of Well Completion

05 Stan Rae Head of Geoscientist

06 Graeme Rae Head of Petroleum Engineering

07 Wan Nawawi Head of Reservoir Engineering

08 Paul Tipton Drilling Fluid Advisor

09 Abdul Halim Shariff Drilling Engineer

10 Shairizal Shaite Drilling Engineer

11 Shazwan Ramli Drilling Engineer

12 Hamiraj Abdul Hamid Drilling HSE Advisor

13 Drilling Supervisor Petrofac Offshore Representative

14 Completion Supervisor Petrofac Offshore Representative

15 Shelf Drilling Rig Contractor

16 KST Tubular Handling Service Provider

17 Halliburton HCT Completion Service Provider

18 Solar Alert Wellhead Service Provider

19 Deleum Slickline Service Provider

20 Schlumberger TCP Service Provider

21 Schlumberger Wireline Service Provider

22 Halliburton CWT Wellbore Cleanout

23 Halliburton Baroid Completion Fluid Service Provider

24 Neural Pressure Downhole Gauge Provider

25 Schlumberger Smith Fishing Service Provider

26 Maxtube PSI GRE tubing supplier


PML-PR-D-0329

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PREFACE

Purpose

The purpose of this document is to detail the procedure for completion program in accordance with Petrofac Group practice.

It defines the roles and responsibilities for personnel involved.

Review and Update

The Technical Authority for this document is the Completion Engineer who should also be consulted if further information on the subject matter is required. The Technical Authority is also responsible for the accuracy of information contained within this document, and will decide the allocation of the copies.

The document is subject to annual review and update, when document holders have the

opportunity to express opinions and suggest improvements.

Additionally the control system allows for continuous update to the document. Any approved user may at any time identify an error or suggest an improvement.

Responsibility of Copyholders

It is the responsibility of the registered copyholder to maintain the accuracy of this document by ensuring that all updates are promptly incorporated and acknowledged.

Furthermore, the registered copyholder must at all times maintain custody of this document unless prior approval is given by the relevant Document Custodian or Technical Authority.


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TABLE OF CONTENTS

1. CONTACT LIST ..................................................................................................... 6

2. PURPOSE/SCOPE/OBJECTIVES ............................................................................. 8

2.1 PURPOSE .............................................................................................................................................. 8 2.2 SCOPE ................................................................................................................................................... 8 2.3 OBJECTIVES ........................................................................................................................................ 8

3. RELATED DOCUMENTATION ................................................................................ 9

4. MANAGEMENT OF OPERATION .......................................................................... 10

4.1 GENERAL............................................................................................................................................ 10 4.2 CONTRACTOR WELL SITE OPERATIONS ....................................................................................... 11 4.3 MEETINGS .......................................................................................................................................... 12

5. WELL STATUS .................................................................................................... 14

6. PROPOSED WELL SCHEMATIC ............................................................................ 15

7. PROCEDURE OUTLINE AND TIMELINE................................................................ 16

8. WELL AND RESERVOIR DATA ............................................................................. 17

9. PERFORATION STRATEGY .................................................................................. 17

10. COMPLETION FLUID/BRINE STRATEGY .......................................................... 18

11. GAS LIFT MANDRELS SETTING DEPTH ........................................................... 18

12. POB PLAN ....................................................................................................... 19

13. COMPLETION PREPARATION .......................................................................... 20

14. WELLBORE CLEAN OUT PROCEDURE (AFTER CEMENTING) .......................... 25

15. CEMENT EVALUATION LOG PROCEDURE ....................................................... 26

16. RUNNING COMPLETION STRING PROCEDURE ( I-TCP) .................................. 27

17. SPACE OUT STRING AND LAND TUBING HANGER .......................................... 29

18. TUBING INTEGRITY TEST, INFLOW TEST & SET PACKER .............................. 30

19. NIPPLE DOWN BOP & NIPPLE UP CHRISTMAS TREE ...................................... 31

20. WELL PERFORATION & CLEAN UP FLOW (OFFLINE)..................................... 32

21. ATTACHMENT ................................................................................................. 35


PML-PR-D-0329

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1. CONTACT LIST

PETROFAC OFFICE TEAM

Name Position Office Mobile Email

Karen Stanley Drilling & Completion Manager

03-2301 5290 019-673 9987 [email protected]

Charles Stirrett Drilling Superintendent 03-2382 2761 019-270 4008 [email protected]

Edwin Damasena Head of Well Engineering 03-2382 2771 019-273 2771 [email protected]

Hamizan Maksari Head of Well Completion 03-2382 4566 019-571 1585 [email protected]

Halim Shariff Drilling Engineer 03-2382 3733 019-200 8099 [email protected]

Shairizal Shaite Drilling Engineer 03-2382 5433 019-346 1403 [email protected]

Shazwan Ramli Drilling Engineer 03-2382 2760 019-286 0411 [email protected]

Paul Tipton Drilling Fluid Advisor 03-2725 4518 019-268 2829 [email protected]

Syahir Wafa Ulul Azmi Drilling Materials and Logistic Coordinator

03-2382 4559 019-790 4559 [email protected]

Adam Sulaiman Drilling Materials and Logistic Coordinator

03-2382 5292 019-277 4559 [email protected]

Hamiraj Fahry Drilling HSE Advisor 03-2382 3734 017-662 6350 [email protected]

Zahid Zakaria KSB Base Superintendent 09-863 3702 019-266 9920 [email protected]

Rizal Zakaria KSB Materials and Logistic Coordinator

09-863 3702 019-293 5348 [email protected]

COMPLETION CONTRACTOR TEAM

Company Name Office Mobile Email

Halliburton Completion

Ikmal Hakim

Mohd Eliyas Yaakob

Roderick Barrett

03-9206 6888

017-299 2977

019-451 4345

012-612 8734

[email protected]

[email protected]

[email protected]

Schlumberger TCP Kuljit Khaira

Ganesh Morati 03-2166 7788

017-602 0422

012-515 6464

[email protected]

[email protected]

Schlumberger E-line Kuah Tien Chen

Normalisa Sarupi 03-2166 7788

012-218 7115

012-270 7685

[email protected]

[email protected]

Neural PDG Marcel Berthele

Fitril Fahmi 03-5031 0088

012-220 7911

012-719 1124

[email protected]

[email protected]

Deleum Slickline Norsaiful Bin Rosli 03-2295 7788 019-628 3008 [email protected]

Dialog Filtration Fuad Hashim

Fauzie Mohd Farid 03-7955 1199

019-383 9934

013-711 7940

[email protected]

[email protected]

KST TRS Ansharullah Hassan 03-2282 4884 017-769 4264 [email protected]

Solar Wellhead Anuar Mos

Hj Hilmi 03-5740 8600

013-585 2600

012-373 8255

[email protected]

[email protected]

mailto:[email protected]

























PML-PR-D-0329

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Halliburton Completion Fluid

David Phillips

George Paul 03-9206 6888

012-934 0847

012-339 0076

[email protected]

[email protected]

Cementing Nurul Aisyah 03-2166 7788 019-434 7483 [email protected]

Smith Fishing Aiman Thalaha

Michael Smalley 03-2166 7788

019-455 2412

012-294 6442

[email protected]

[email protected]

Halliburton WBCO Salam Rojaie 03-9206 6888 014-911 6067 [email protected]

Fearnley Procter QAQC

Jaafar 09-863 3702 019-389 8527 [email protected]

Rig Manager Garry Lewis 03-2303 1000 017-615 3332 [email protected]

Maxtube GRE Kevin Bruce +971 4 8123845 +971 50 1005173 [email protected]

TRIDENT IX TEAM

Name/Office Office Email

Drilling Supervisor Ofiice 03-2382 2721 [email protected]

Drilling Materials Man Office 03-2382 4526 [email protected]

Well Site DE 03-2382 2759 [email protected]

CSV office 03-2382 4501 [email protected]

Service Company 03-2382 4568 -

OIM Office +65 6572 7652 [email protected]

Radio Room +65 6572 7650 [email protected]

















PML-PR-D-0329

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2. PURPOSE/SCOPE/OBJECTIVES

2.1 PURPOSE

This document operational procedures and associated references for the installation of the downhole well completion equipment and Xmas tree on the West Desaru A Development wells where the production casing has been cemented across the reservoir section.

2.2 SCOPE

The West Desaru A Development wells will be drilled and completed from the WD-A wellhead platform using the Jack-up Drilling Rig Trident IX (JUDR).

The Jack-up rig operations will be under taken simultaneously with oil production operations and being carried out in nearby MOPU platform and concurrent project construction activities. Overall control of the drilling/completion activities will therefore be governed by procedures within the PML SIMOPS (Document No PML-PR-D-0251 Rev1) as well as the Jack-up Rig HSE System Bridging favourable.

2.3 OBJECTIVES

The objectives of the completion programme are to install the well completion to meet programme specifications herein with no accidents or incidents, minimal environmental impact and within the planned time and budget.

The objective of this WD-A15 is to drill and complete as a single string water injector to provide pressure support to producers located in the northern section of the West Desaru main fault block in the H-15 reservoir. The H-15 will be perforated using 4-1/2” integrated tubing conveyed perforation (iTCP) gun assembly. The iTCP gun will be run as part of the completion tubing.

THE SAFETY OF PERSONNEL AND THE INTEGRITY OF THE WEST DESARU INSTALLATION, THE DRILLING RIG, AND ASSOCIATED EQUIPMENT ARE PARAMOUNT.


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3. RELATED DOCUMENTATION

Item Number

Title

CONTRACTOR DOCUMENTS Baroid Material MSDS Manual Schlumberger : USIT/CBL Logging Procedure Halliburton (Completion Tools) : Design of Service

Neural : PDG Installation Procedure Schlumberger : i-TCP Running Procedure

Solar Alert: Wellhead Operating & Installation Manual PML REFERENCES SPD-HSE-001 SPD-HSE-GUI-004 SPD-HSE-GUI-005

HS&E Management System Risk Management Guideline Management of Change

SPD-HSE-GUI-006 Contractor Management of Change SPD-HSE-GUI-008 Incident Reporting Monitoring Non-Conformance SPD-WEMS-001 Well Engineering Management System Manual SPD-WEMS-POL-001 Drilling Policy Manual SPD-WEMS-STD-001 Well Design & Construction Manual SPD-WEMS-STD-003 H2S Contingency Plan Manual SPD-WEMS-STD-005 Corrosion and Materials Selection Manual SPD-WEMS-STD-006 Well Handover Manual SPD-WEMS-STD-007 Hazardous Material & Waste Management Manual SPD-WEMS-STD-008 Simultaneous Operating Manual SPD-WEMS-STD-009 Barrier Philosophy Manual SPD-WEMS-STD-010 Well Dispensation Manual SPD-WEMS-STD-011 Well Integrity Manual SPD-WEMS-STD-012 Well Control Manual SPD-WEMS-STD-015 Lost Circulation Plan Manual SPD-WEMS-STD-016 Well Testing Standard Manual SPD-WEMS-STD-017 Completion Standard Manual WD1-9100-00-HU-PRO-0005-REV1

Standard Operating Procedure: Well Handover Procedure West Desaru Well head Platform A

WD1-PR-O-0069 West Desaru Well Start Up Procedure PPGUA JUDR (TRIDENT IX) REFERENCES HSE System Bridging Document Permit To Work Manual


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4. MANAGEMENT OF OPERATION

4.1 GENERAL

This programme is issued under the authority of the PML Drilling & Completion Manager. No activities covered by this programme may be commenced until their approval or their delegate’s approval, indicated by signature on the front cover, has been obtained.

Without prejudicing emergency requirements, any deviation from this programme must be approved by the PML Drilling & Completion Manager, or his delegates. A programme deviation must be issued and approval indicated by the signatures of the PML Drilling & Completion Manager, or their delegates, prior to commencement of any activities covered by a programme deviation

The JUDR rig OIM is the Senior Contractor Representative onboard the rig and is responsible for the safety of the rig and all personnel on board. He shall ensure that all drilling rig activities are carried out safely and do not infringe on the SIMOPS procedure.

The Drilling Supervisor is the senior authority offshore responsible for this programme and it is his responsibility to ensure that this programme is carried out in a safe and sound manner in accordance with PML policies, standards and standard procedures, Contractor and Vendor procedures, any regulations imposed by regulatory authorities and industry codes and standards.

The Completion Supervisor reports to the Drilling Supervisor offshore. Drilling Supervisor is responsible for the offshore implementation to ensure the objectives of the completion programme are met. The Drilling Supervisor as deemed appropriate will delegate responsibility for the supervision of the completion activities covered by this programme to the Completion Supervisor.

Service Company Contractors shall designate a Supervisor who will be responsible for safe operation of their equipment and field operational reporting throughout the well completions. The Contractor Supervisor is to submit a daily operational report to the PML Drilling Supervisor and Completion Supervisor.

The Service Companies directly involved with the well completions are listed below against their area of operation.

Area of Operation Service Company

Rig Operations Trident IX

Drilling & Completion Fluids Halliburton Baroid

Casing Scraper Halliburton CWT

Filtration Dialog

Casing & Tubing Running Samudra Oil KST

Completion Equipment Halliburton HCT

PDG Equipment Neural

Cementing Unit Dowell Schlumberger


PML-PR-D-0329

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Wellhead & Xmas Tree Solar Alert

Slickline Deleum

Wireline Logging Schlumberger

TCP Schlumberger

Fishing Tools Smith International

GRE Maxtube/PSI

Each Service Company shall have an Onshore Representative on call 24 hrs a day throughout the well completion rig activities.

The Contractor/PML/JUDR documents and standard procedures referenced in this programme will be available offshore. It is the responsibility of the Drilling Supervisor and the Completion Supervisor to ensure that all personnel have access to and have read and understood these procedures as appropriate.

Prior to the commencement of any new operation the Drilling Supervisor and Completion Supervisor will ensure that a safety and operations briefing is held with all relevant personnel.

All ‘cold’ and ‘hot’ work to be carried out during this Programme will be carried out under the JUDR or MOPU Permit To Work System.

Roles & Responsibility flowchart as below:

4.2 CONTRACTOR WELL SITE OPERATIONS

The Contractor must ensure that all of their personnel working on the well site are equipped with the appropriate PPE to perform their duties.


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Contractor’s to prepare JSA sheets to cover all routine operations and contingent operations expected during the well completion programme. The JSA must indentify all potential hazards and have controls in place to mitigate the hazards.

Upon arrive at the rig the Service Company Supervisor must review operational requirements specific to the drilling rig and revise JSA sheets accordingly.

Contractors must provide MSDS’s on all materials to be used during the completion operations and identify use, potential hazard & controls in their JSA and at work site safety / toolbox meetings.

When working at heights above 6 ft, the Contractor Supervisor must ensure there is adequate support equipment in place to enable personnel to safely perform their work. A particular example is the provision of scaffold platform around the wellhead & Xmas tree to safely work on or rig up on the Xmas tree. Prior arrangements to be made with the JUDR OIM to use construction scaffolding.

4.3 MEETINGS

The following meetings are a minimum requirement prior to and during the completion:

Complete Well On Paper (CWOP) Meeting

A CWOP meeting to be held onshore prior to mobilisation of equipment & personnel to the rig. The PML Completion Engineer will chair the meeting with the Service Company onshore representatives and well site Supervisors in attendance. The purpose of the meeting:

Drilling & well completion timing update

Establish logistical requirements for the completion campaign

Review Roles & Responsibilities and manning levels on well site

Critically review the well completion programme with a view to identifying potential operational problems & hazards. Discuss and/or action to ensure resolution of all issues be raised.

Establish Contractor specific work scope including JSA highlights, back up equipment & spares and contingency operations.

Service Company representatives should be prepared to give a 10 – 15 minute presentation on the last point above with emphasis on hazard identification and mitigation. All Contractors to provide full equipment inventory, including dimensions & weights for shipping, and to specify what equipment preparations and QC checks will be done onshore prior to load out.

Apart from reviewing the well completion programme requirements, one of the main objectives of the meeting is for Contractors to interface with each other to identify & resolve related issues so there is a common understanding and no surprises when on the well site. The meeting is also a forum for Contractors raise any issued related to the well completion campaign.

Completion Operations Meeting

The Drilling Supervisor and Completion Supervisor will conduct an on-site operations meeting at a convenient time prior to commencement of completion operations to outline the completion objectives and operations, both programmed and contingent. The meeting is to cover all rig crew shifts with rig management and appropriate service company personnel in attendance.

Rig Floor & Work Site Safety / Toolbox Meetings

A meeting shall be conducted prior to any new or critical operations whether on the rig floor or any other work site on board the rig or platform. PML supervisory


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staff, Tour Pusher, rig crew and Service Company personnel involved in the operation are to attend. The meeting will be chaired by the PML. The relevant Service Contractors will explain the operations and material & equipment to be used and the potential hazards and controls in place to manage hazards and safely execute the operations. Complete a contractor JSA where applicable.

Weekly Safety Meeting

The Drilling Supervisor and the OIM conduct a weekly Safety Meeting to discuss the past weeks operations and the upcoming operations to be performed, this will act as a forum for all personnel on the rig to put forward their ideas and for any lessons learnt to be addressed prior to the any subsequent operations. The Completion Supervisor will attend and provide input to the meeting as necessary. All Service Company personnel are required to attend.

Meeting Documentation

All meetings held at the well site as discussed above are to be noted in both the JUDR IADC report and the PML DDR.


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5. WELL STATUS

All well depths are Measured Depth Drill Floor (MDDF) unless otherwise stated:

Slot Location (centre) N 5 o 35’ 10.64487”, E 104o 28’ 34.54290”

TVD Reference Datum: Rotary Table

TVD Reference Elevation: 42.8 m above Mean Sea Level (AMSL)

Seabed / Ground Elevation: 64.8 Below Mean Sea Level (BMSL)

Xmas Tree (to be installed) Xmas Tree Dual, 3-1/8” 5K MODEL SAE S.G.V 3-1/8” 5K Wing Valve, 2-1/16” 5K Kill Line Valve, 7-1/16” 5K FLG BTM

Well Name WD-A15

Platform Slot No.: Slot 7 (Location WI-02)

Designation Single Water Injector (c/w Dual Tree)

Rig RT Elevation: 42.8m AMSL

Wellhead Depth (Tubing Head Flange) Xmas Tree Cap Depth

21.2m AMSL 23.9m AMSL

Casing shoe: 36” (553 ppf) 185 m MDDF / 142.2 m TVD SS

18-5/8” (87.5 ppf) 184 m mDDF / 141.2 m TVD SS

13-3/8” (68.0 ppf) 870 m MDDF / 658.2 m TVD SS

9-5/8” (47.0 ppf) 2203 m MDDF / 1093.8 m TVD SS

7” (29.0 ppf) 3400 m MDDF / 1481 m TVD SS

TD (est): 3530 m MDDF / 1483 m TVD SS

PBTD (est): 3470 m MDDF / 1453 m TVD SS

Well Shape J

Max Deviation (deg.) 72.1 deg

Reservoir Target Depth Top H-15 sand (3317m MDDF / 1455m TVD SS)

Max Reservoir Pressure (psia): 2197 psia @ 1456 m TVD SS

Max Mud Weight (ppg) 11.8 ppg

Max Reservoir Temp. (oC) 89 oC @ 1456 m TVD SS

Max SITHP (psi) 1,800 psi


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6. PROPOSED WELL SCHEMATIC

Well ID : WD-A15 Casing : 36" Conductor @ 185 m MD

Location : WI-02 : 13-3/8" casing, 68ppf, N-80, Ultra FF @ 870 mMD

Rig : Trident IX : 9-5/8" casing, 47ppf, L-80, Vam Top @ 2203 mMD

Wellhead : Single Wellhead, 3-1/2" Dual Xmas Tree : 7" casing, 29ppf, L-80, JFE BEar @ 3528 mMD

THF : (-/+) 21.2m MSL Tubing: : 3-1/2", 9.2 ppf, L-80 GRE Tubing, JFE Bear DDLAA

DF Elevation : 42.8 m MSL (Max OD. = 4.250", Min I.D w/Lining. = 2.670",Drift I.D. = 2.545")

Max Deviation : 72.1 deg @ 2,293m MDRT

PBTD : 3470.0 m MDDF Completion Fluid : Seawater

Water depth : 64.8m Packer Fluid: : Seawater + Corrosion Inhibitor + Biocide + Oxy Scavenger

Slot : 7

Date of Completion : Nov 2014 All depths to top of equipment

Min ID Max OD Incl MD MD Min ID Max OD

inch inch (mRT) (mRT) inch inch

Dual Tubing Hanger: 3-1/2" Dual Tubing Hanger : 3-1/2"

3-1/2" x 2-7/8" Flow Coupling 2.390 3.400 49.7 3-1/2" Bull Plug - 3.318

2-7/8" SP-TRSSSV (2.313" X-profile) 2.313 5.410 0.0 145.0

2-7/8" x 3-1/2" Flow Coupling 2.390 3.400

2-7/8" SSD (2.313" Bore) 2.313 3.920 60.0 750.0

13-3/8" SHOE @ 870 mMD

3-1/2" GRE Tubing, 9.2 ppf, L80 JFE Bear DDLAA 2.670 4.250

7" TOL @ 2100 mMD

9-5/8" SHOE @ 2203 mMD

3-1/2" PDG 2.963 5.950 71.0 2750.0

2-7/8" X-Nipple (2.313" Bore") 2.313 3.897 71.0 3240.0

7" AHC Packer 2.390 5.930 71.0 3250.0

2-7/8" SSD (2.313" Bore) 2.313 3.920 71.0 3260.0

3-1/2" w/ Ricewrap , 9.2 ppf, L-80 GRE Tubing 2.670 4.503

2-7/8" XN-Nipple (2.313" Bore") 2.205 3.898 71.0 3270.0 JFE Bear DDLAA

3-1/2" x 2-7/8" X-over 2.431 3.878 71.0 3280.0

2-7/8" POUV 2.250 4.000 71.0 3290.0

EOT/SXAR 3.680 71.0 3300.0

H-15 SandInterval: 3314 - 3378 m MD

Top of ITCP fish @ 3396.0 m m

4-1/2" ITCP Gun

PBTD 71.0 3470.0 Drawn by: Aqbal

8-1/2" HOLE TD 71.0 3530.0 Approved by: Hamizan Maksari

Date : 27 Nov 2014

PROPOSED COMPLETION WELL SCHEMATIC - 3 1/2" SINGLE WATER INJECTOR (Rev 0)

Long String Short String


PML-PR-D-0329

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7. PROCEDURE OUTLINE AND TIMELINE

(For Planning Purposes Only)

Time

Plan

Time

Actual

Cum

Time

Ops Section Activity

hrs hrs days

2.00 0.08 1 PJSM. RU surface equipment to run WBCO.

18.00 0.83 Pick up 3-1/2" DP. Make up and start RIH clean out BHA / casing scraper.

8.00 1.17 Casing Circulate and work scraper / brusher to TD.

12.00 1.67 Clean-Out Pump pill train & circulate clean w/ SW until TSS < 0.05%. Pressure test casing.

6.00 1.92 P/U jet sub and jet BOP. POH to pkr depth. Displace well to packer fluid. Flow check.

8.00 2.25 POOH and L/D scrapers / brushes.

2.00 2.33 2 Recover wearbushing.

3.00 2.46 PJSM. RU handling equipment to run completion.

8.00 2.79 Run TCP perforation gun

36.00 4.29 RIH ITCP Continue RIH completion string

4.00 4.46 Completion MU and run TRSV; pressure test control line.

8.00 4.79 Continue RIH completion.

2.00 4.88 Tag HUD. Space out string.

3.00 5.00 MU tubing hanger. Terminate/feed lines and pressure test all lines.

3.00 5.13 Land tubing hanger. Secure tie down bolt.

2.00 5.21 3 PJSM. RU circulating sub and test line.

5.00 5.42 Set Pkr Tubing Tests, set pkr, Inflow Test TRSV, shear POUV and test packer from below.

3.00 5.54 & N/U Lay down landing jts, cut control lines.

4.00 5.71 X-mas tree Install BPV in tubing hanger. Rig down tubular handling equipment.

9.00 6.08 Rig down divertors. Nipple down BOP.

7.00 6.38 Install Xmas Tree and test same.

1.00 6.42 Well handover to HUC for tie-in.

2.00 6.50 4 R/U Slickline and Line up Surface Pumping.

2.00 6.58 Run shifting tool. Open SSD.

2.00 6.67 Fire gun Pump nitrogen through tubing. Circ thru SSD.

2.00 6.75 & clean Run shifting tool. Close SSD.

3.00 6.88 up well R/D Slickline.

10.00 7.29 Activate iTCP gun, flow back and start to clean up well.

154.00 6.42 days (Plan) 0.00 days (Actual)

WD-A15 WELL COMPLETION TIME PLANNER

End of operation.


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8. WELL AND RESERVOIR DATA

The reservoir data for this well can be summarized as per Table 8.1 below:

No.

Formations

Depth

(m-TVDss)

Estimated Pressure

(Psia)

Predicted

Temperature Celsius (0C)

1 H15T2 1456 2197 89

Table 8.1: Formation / Reservoir Data for target sands

9. PERFORATION STRATEGY

The perforation plan for this well can be summarized as per Table 10.1 below:

Target Sand: H:15

Perforation Interval 3,314 – 3,378 mMDDF (64 m)

Perforation Method e-Fire I-TCP

Fluid Cushion Sea Water

Underbalance Min 500 psi

Gun Size 4-1/2”

Type of Charges HSD, Powerjet Omega 4512 HMX

Shot per foot 12 spf

Table 9.1: Perforation Data


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10. COMPLETION FLUID/BRINE STRATEGY

The completion brine strategy can be summarized as per Table 10.1 below. The pit management plan for this well can be found in Attachment 2.

Fluid Type Fluid Density Fluid Design

Completion fluid 8.6 ppg Sea Water

Packer fluid 8.6 ppg Sea Water + 0.5 ppb Biocide + 0.5 ppb Oxygen Scavenger + 1% Corrosion Inhibitor

Table 10.1: Completion Fluid Program

11. GAS LIFT MANDRELS SETTING DEPTH

No gas lift mandrels will be installed in this well.


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12. POB PLAN

Below is the POB plan during completion phase:

No. Description / Operation Sequence Company / Job Role No. of Personnel

Online Completion

1 Completion Supervisor Petrofac 2

2 Wellbore Cleanout Halliburton / WBCO 1

3 TCP Schlumberger / TCP 2

4 Tubular Handling KST 5

5 Upper completion run Halliburton / Upper Completion 3

6 Downhole Gauge Neural/ PDHG 4

7 Tubing Hanger & X-Mas Tree Solar Alert / Wellhead 2

8 Pip Tag Schlumberger / Wireline 1

20

Regular Rig POB

1 DSV (Day) + DSV (Night) 2

2 WSDE 1

3 Materialsman 1

4 Mud Engineer 2

5 Cementer 2

6 Mud Logger 2

10

Rig crews 66

66

96

Offline Completion / Well Clean-up

1 Completion Supervisor Petrofac 1

2 Tubing Hanger & X-Mas Tree Solar Alert / Wellhead 1

3 Slickline Deleum 3

4 Nitrogen Setegap Venture Petroleum 4

5 TCP Schlumberger / TCP 1

10

TOTAL POB

*REMARKS: POB plan will change subjected to operation requirement

Total POB for ONLINE Completion

Total POB for OFFLINE Completion

Total Petrofac & Regular 3rd Party (Drilling)

Total Rig crews


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13. COMPLETION PREPARATION

Each Service Company Representative or Supervisor is to check their equipment list, ensure adequate back-ups & spares and that their equipment functions correctly, and to report any problems or discrepancies immediately to the PML Completion Supervisor or the PML Drilling Supervisor.

A. Drilling BOP Stack Configuration for Completion Operations

The drilling BOP stack is to be configured as below and tested accordingly prior to commencement of the completion operations.

Drilling Perforation Completion

Annular Hydril Hydril Hydril

Top Ram 4-1/2” – 7” 4-1/2” – 7” 4-1/2” – 7”

Middle Blind/ Shear Blind/ Shear Blind/ Shear

Bottom 3-1/2” - 5-1/2” 3-1/2” - 5-1/2” 3-1/2” - 5-1/2”

B. Mud Pits, Filtration and Completion/Packer fluid

Prior to commencing the clean out operations the management of the pit system is to be discussed by the Drilling Supervisor, Toolpusher, Mud Engineer and Completion Engineer / Supervisor in order to ensure efficient execution of the clean out

Surface preparation prior to Wellbore Cleanout and Displacement operation will be based as per Attachment 2: Pit Management.

Record pit status after the well is cased off. Define all pits used for the completion as active.

Consider the pit’s dead volume during pumping.

Check NTU reading in all pit prior to hole displacement.

Specification or target (return fluid)

pH : 7 to 9

NTU : below 50

TSS (Total Suspended Solid): below 0.05 % by volume

Shaker area – redressed shaker with used 250 mesh or higher (1 shaker shall be sufficient). Take return through shaker screen (to observe any debris) and bypassed the sand traps and dump overboard.

Place magnet on flow line.

The BOP test date is to be checked to ensure a test will not be required before the end of the completion. If the current test will expire before the end of the completion operation conduct a new BOP test before RIH. On batch completions, the BOP test will be conducted when nippled up. There has been previous experience with the BOP test tool getting stuck in the casing below the wellhead when RIH with any attachment on bottom. Check to be sure that any equipment below the tool that extends into the casing is within casing drift.

If PBTD on the scraper is higher than expected and / or there is insufficient rathole to accommodate the full length of the dropped TCP gun assembly with allowance for an MPLT toolstring below the bottom perforation, drilling out excess cement and a portion of the shoe track may be required.


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C. Completion Tubular

The completion tubing and sub-assemblies are made from Carbon Steel tubing with Glass Reinforce Epoxy (GRE) internal lining. There are also some joints with RiceWrap on the external pipe of the body. RiceWrap® is an external fiberglass epoxy material applied directly to the external pipe body for corrosion prevention. The materials of fiberglass and epoxy are identical to those used to fabricate the DUOLINE 20 internal lining system, and will have similar chemical resistance.

All connections must be handled and inspected in accordance with the recommended procedures for handling & transit. This also includes the exposed fibreglass flares on the pin ends. Never handle pipe with open end protectors and end hooks as the hooks can easily damage the liner or flares. The pipe manufactures and liners will normally supply the product with closed end protectors. This is the preferred method of protecting the threads and liner. Ensure that these are correct and intact before starting to remove the protectors.

No cracking will be accepted on face of the flare as this is the surface which comes in contact with the DL- CBR. Slight cracking is acceptable on the tapered section of the flare providing that it does not propagate onto the flare 'face'.

Should impact damage be visible on the flare face (as a result of transit damage or misstabbing'), this will be deemed acceptable as long as the damage does not exceed 30% across the face width. Flare damage in excess of the above criteria will be cause for rejecting the joint.

Pre-running drifting is not recommended due to potential flare damage when removing the drift from the pipe.

The flares are glued to the ends of the fibreglass. Check that this is securely in place during running by tugging lightly on the flare. If the flare comes off then the joint must be rejected.

As is normal practice, the connections must be spotlessly clean prior to application of the thread compound. This includes removal of any storage compound or oils that may have been applied to the connections.

Check that there are sufficient DL- CBR rings available at the rig site. One DL-CBR must be inserted in each coupler.

Drift OD will be 2.545”.

Refer to Attachment 7: GRE/RW Tubing Data Sheet and Attachment 11: JFE Duoline Field Procedure for more detail information.

D. Completion Sub-assemblies

All the completion accessories will be made up into sub- assemblies for easier handling and make up offshore.

The sub-assemblies have been made up to the optimum torque, drifted & internally p/tested to 5000 psi and packaged in the completion baskets for shipment to the rig.

Upon arrival at the rig, the primary set of sub-assemblies should be unpacked and laid out on the deck supported by wooden lined or suitably padded beams for inspection.

Remove transport packing and hose down all sub-assemblies with fresh water when received on the rig.

Each sub assembly is to be visually inspected and re-strapped. Any discrepancies to be noted on the tally sheet.

Rig Crew to remove tubing thread protectors, clean & dry threads, visually inspected threads, and re-install the protectors.


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Prior to re-installing thread protectors, sub-assemblies will be drifted with the 2.313” HES drift by the HES crew on deck.

Remove all tape and loose debris from the sub-assemblies.

Remove thread protectors and function test TR-SCSSV and p/test hydraulic chamber to 6,500 psi. Record opening/closing pressures and volume bled back from 6,500 psi.

Mount TR-SCSSV c/line spool on spooling unit. Completely flush the spool of c/line with Shell Tellus 32 oil and then p/test the c/line to 7,500 psi / 10mins.

Neural to carry out deck testing (full interface & operational checks) on all PDG equipment in accordance with the well system sheet and relevant work instructions in the Neural Cendor PDG Project Rig Book.

Solar Alert to inspect tubing sub assembly and the install Tubing Hanger Running Tool (THRT) assembly onto the tubing hanger.

Prepare tubing completion running list and distribute copies as appropriate to all personnel/crews directly involved in running the sub-assemblies & tubing.

E. Landing Joints/ Riser

The landing joint for this completion will be 3-1/2” 9.2 ppf L80 JFE Bear B-P tubing and pup joints.

Top landing joint crossovers :

1) 4-1/2” IF (Box) x 3-1/2” JFE Bear (Pin)

2) 4-3/4” – 4 ACME 2G (Box) x 3-1/2” JFE Bear (Pin)

Bottom riser joint crossover (above the Xmas tree):

1) 4-3/4” – 4 ACME 2G (Box).x 4-1/8” – 4 ACME (Pin)

2) 3-1/2” JFE Bear (Box) x 4-1/8” – 4 ACME (Pin)

The well control assembly need to ready on the rig floor. All crossover will be available during well control situation, rig up the slickline and electric line PCE operations.

Prepare landing casing joints, pup joints & crossovers as follows:

Rig crew to remove thread protectors, clean & dry threads and protectors, and visually inspect threads for damage.

Rig crew to drift all tubing joints, pup joints and crossovers with API Teflon mandrel.

Strap and number each joint & pup joint.

Record lengths in running tally spreadsheet for landing joint space out.

F. Slickline Equipment (*Back up)

Deleum to ensure all slickline running equipment is fully serviced & functional and there are adequate spares on critical items during the completion phase.

The following pre-completion preparations should be made:

Inspect & inventory Deleum slickline/wireline running & pulling tools and plugs & redress kits. Two sets of equipment for the following equipment:

2.313” XN blanking plug w/ prong

2.313” X blanking plug w/ prong

2.313” N Test Tool plug

2.125” Roller Boogies


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Deck test slickline BOPs to 5000 psi.

Check that all X-over connections on PCE and fit together and mate to the landing string & riser and Xmas tree cap :

4-3/4” – 4 ACME 2G (Box) x 3-1/2” JFE Bear (Pin).

Ensure sufficient length of hydraulic line to open / close the TR-SCSSV

G. Wireline Equipment (*Back up)

Schlumberger to ensure all wireline running equipment is fully serviced & functional and there are adequate spares on critical items during the completion phase.


Inspect & inventory Schlumberger wireline running tools, associate equipment and redress kits.

Deck test wireline BOPs to 5000 psi.

Check that all x-over connections on PCE and fit together and mate to the landing string :

4-1/2” IF (Box) x 3-1/2” JFE Bear (Pin)

*Contingency plan. No need to call out unless it is required.


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H. Xmas Tree

The Xmas trees will be delivered to the rig with the tubing head adapter and factory tested.

Installation of the Xmas tree onto the compact housing wellhead will be done with sling using the Solar Alert guide screw. To accomplish this, the tree must be position on the platform weather deck and hang accordingly to wire sling. Tree has been function tested on weather deck by hook up team.

Upon arrival at the rig, check the following:

3” HBPV is onboard.

The UMV actuator is to be opened fully and a fusible lock open cap installed.

Remove the Xmas tree cap, open LMV & SWAB. Inspect and clean excess grease from the tree bore.

Drift tree bore with the 3” OD drift mandrel to ensure free passage of the 3” HBPV.

Check the landing crossovers for the tree cap are available.

Once installed access and safe operation of the Xmas tree valves & tree cap should be via a suitably erected scaffold work platform.

Arrange scaffold erection through Rig OIM & construction contractors.

I. Well Perforating (TCP)

Schlumberger to ensure all perforating equipment is fully serviced & functional and there are adequate spares on critical items during the completion phase.


In consultation with PML Drilling Supervisor, establish a suitable location for explosive magazine.

Under direction from PML Drilling/Completion Supervisor pre-load perforating guns as required.

PML Completion Supervisor to witness and verify the setting of e-fire pressure profile.

Check that crossover quantity needed for I-TCP perforation is available on rig floor.

3-1/2” JFE Bear (Box) x 2-7/8” JFE Bear (Pin)

2-7/8” JFE Bear (Box) x 2-7/8” EUE (Pin)


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14. WELLBORE CLEAN OUT PROCEDURE (AFTER CEMENTING)

The objective of the wellbore clean out operation is to remove the drilling SOBM in the hole and clean out the well for final displacement to completion fluid. The SOBM in the hole will be cleaned up as much as possible using seawater before the hole being displaced with completion/packer fluid.

Below is the operation sequence:

1) PJSM – Hazard involved in running wellbore clean out operation.

2) Set wear bushing w/ 8.8” ID.

3) Make up WBCO assembly as per Attachment 4.

6” Rock bit

7” Combo Tech Scraper

7” Mag Tech + 10’ pup joint w/ 3-1/2” IF

3-1/2” IF DP to top of 7” liner (need to be drifted min 1.75” Drift)

4) Continue to make up WBCO assembly as per Attachment 4.

X-over from 3-1/2” IF to 4-1/2” IF

9-5/8” Combo Tech Scraper

9-5/8” Vali Tech

9-5/8” Mag Tech

10’ pup joint w/ 4-1/2” IF + X-over from 4-1/2” IF to DSTJ 5-1/2” FH

5) Continue RIH with 5-1/2” DP while break circulation on every 10 stands.

6) Record Pick Up and Slack off weight prior to enter top of liner.

7) Continue RIH WBCO assembly to proposed packer setting depth @ 3,250 m MDDF.

8) Reciprocate scrapers several times across proposed packer setting depth from 3,200m to 3,300m with a minimum 3 passes.

9) Stop 1 stand before est. PBTD @ 3,470m MDDF.

10) Perform precautionary wash down & tag 2-3 klbs on PBTD.

11) Pick up to last PU weight plus 1m.

12) Circulate 1.5 bottoms up at max. allowable pump rate to remove debris from the wellbore.

Reciprocate and rotate during circulation.

13) Pump down pills train as the following:-

50 bbls Base Oil (Sarapar)

100 bbls WBM push pill (1.5 ppb Barazan D, 15% Baraklean Dual, Barite)

150 bbls WBM clean-up pill (15% Baraklean Dual)

14) Displace hole with SW at max. pump rates while reciprocate & rotate clean-up BHA.

The pit must be kept continuously topped up while pumping.

15) Reciprocate string during circulation.

Once the well is considered underbalance, returns will be diverted through choke line. While pump pressure will increase, the flow rate should be maintained as high as possible within the limits of pop-offs.


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16) Once the weighted push pill is on surface, dump returns directly overboard.

17) Measure and record NTU & TSS reading periodically after 1 hole volume circulation with seawater.

18) Stop pumping until NTU < 50 or TSS < 0.05% is achieved or after 1.5 hole volume circulation. (Whichever comes first)

19) Close ram and perform inflow test on 7” liner lap for 30 mins. Record surface and annulus pressure.

20) Remove 9-5/8” pack-off seal injection port plug to check for leaks past the seals.

21) Pressure test casing to 250/4800 psi for 5/15 mins.

22) Pick up one stand and make up jet sub. Jet BOP and wellhead area.

23) Remove jet sub and run back to bottom.

24) While circulating hole with SW, flush all surface lines with SW until clean as follows:

Flush choke and kill line

Flush standpipe manifold and choke manifold

Flush BJ line from pit to rig floor

25) Pull WBCO assembly to proposed packer setting depth.

26) Displace hole with 650 bbls of packer fluid at max rate 12 bpm.

27) POOH workstring and lay down WBCO BHA.

28) Catalog debris and report to Petrofac CSV/DSV.

15. CEMENT EVALUATION LOG PROCEDURE

There is NO requirement to run USIT tool for this well.


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16. RUNNING COMPLETION STRING PROCEDURE ( I-TCP)

A schematic of the proposed 3-1/2” single completion is in Section 7: Proposed Well Schematic. The tubing completion will be run in the well containing seawater.

The completion sub-assemblies and tubing joints will be made up on the rig floor using KST power tongs. All 3-1/2” tubing connection make-up torque values will be monitored and recorded using KST torque-turn computer system.

The following points should be observed during running the tubing completion:

a. Care is to be taken when handling and running the tubing and sub-assemblies as GRE/RW is prone to damage when impacted on steel and galling during connection make up.

b. Tubing or completion sub-assemblies should be picked up with thread protectors installed.

c. Single joints to be pick up direct from transport racks to catwalk for lifting to the rig floor.

d. KST to visually check every pin & box thread on the rig floor prior to make up.

e. Ensure a stab-in safety valve with necessary crossovers is easily accessible on the rig floor at all times.

f. Use stabbing guide at all times during make up.

g. API Modified dope is only to be applied to the last one third of pin ends with a 1” paint brush.

h. For sub- assemblies, walk connections in with a strap wrench or chain tong to the hand tight position prior to placing the make-up tong on the pipe. If a tight spot is detected whilst walking in the connection, do not force it further, break out the connection and examine it for damage or debris.

i. If a torque turns graph shows an unacceptable plot, then the connection must be broken all the way out, cleaned and visually inspected before remaking. Damaged or suspect connections are to be laid out. The applied shoulder torque should be at least 35% of optimum torque but not exceed 65% of optimum.

j. All make up and break outs are to be monitored and recorded by the torque turn computer

k. Ensure to install internal/external CBR ring while RIH tubing.

l. Tubing and assemblies will be made up to at least the optimum recommended torque determined by tubing weight, grade and diameter using a computer analysed make up system.

m. The following torque values are to be used for the tubing:-

3-1/2” 9.2 ppf L80 JFE-Bear Min. Opt. Max. Shoulder

TORQUE VALUES (ft.lb) 3,500 3,870 4,240 581 3,096

Source: JFE (Kawasaki) Supplied

n. Maximum RIH speed is 1 joint per minute slip to slip. Be extra gentle during setting and unsetting the slip.

o. A dog collar is to be used to back the rotary slips until string have substantial weight for slip to hold.

p. Take care when setting rotary table slips around tubing to ensure PDG cable & TR-SCSSV c/line are not damaged.

q. Ensure that a hole cover is in place when working on completion sub-assemblies at the rotary table.


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1) POOH wear bushing.

2) Rig up surface handling equipment for running single completion.

DO NOT perform dummy run for tubing hanger prior to RIH completion.

3) PJSM – Hazard involved in running completion operation.

4) Commence make up of TCP Gun String as per Attachment 5: I-TCP BHA diagram.

5) Lower tugger line from rig floor to catwalk and attach the shackle to the pad eye of Gun 1 lifting sub.

6) Make up Safety Spacer to gun string, a minimum length of 10 ft is required by Schlumberger safety policy to insure Top Shot is below personnel work area.

7) Pick up e-Fire Firing Head assy from main deck to V-Door.

8) Make up FH assy to the upper gun, with e-Fire Firing Head as a primary firing head, and another HDF as backup.

9) Make up 1 joint of 2-7/8” EUE tubing followed by 2-7/8” POUV on top of tubing.

10) Make up 1 joint of 2-7/8” EUE tubing followed by x-over to 2-7/8” JFE Bear.

11) Make up 1 x-over to 3 1/2” JFE Bear followed by 2 pup joints of 3-1/2” JFE Bear.

12) Make up Assy No.1 (2-7/8” XN-Nipple). Cont RIH as per tally.

13) Make up Assy No.2 (2.313” SSD). Ensure SSD in close position.

14) Make up Assy No.3 (7” AHC packer). Check condition and setting pin (STS pin = 6 ea). Continue as per tally.

15) Make up Assy No.4 (2-7/8” X-Nipple).

16) Make up & continue RIH the 3-1/2” 9.2# GRE-L80 JFE-Bear tubing as per completion tally:

Ensure hole covers to be in place. Check Safety clamp regularly.

Inspect threads both pin and box end and apply dope sparingly at pin end only

Use dog collar until sufficient weight for slip to hold the string

Use drift with OD of 2.545” for the tubing jts

17) Make up Assy No.5 - PDG and install TEC cable termination to gauge and function test using surface monitoring software. Refer to Attachment 9: PDG Installation Procedure.

Pressure test cable head connection for 8000psi for 10mins.

18) Continue RIH as per tally, install cross-coupling control line clamp at each joint.

Neural specialist will be responsible to install CLP.

19) Make up Assy No.6 (2.313” SSD). Ensure SSD in close position.

20) Prior to make up TR-SCSSV, check tubing balance on deck and compare with tally.

21) Make up TR-SCSSV and function test 3 times. Connect control line and pressure test 7500 psi for 10mins. Bleed down to 3000 psi and continue to RIH as per tally.

22) RIH until end of TCP gun 40-50 m above target depth.


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17. SPACE OUT STRING AND LAND TUBING HANGER

The objective of this section is to make up the space out pup joints to position gun on depth and to make up the tubing hanger and land in the tubing head spool.


1) Continue RIH completion string slow and tag est. PBTD @ 3,470m MDDF. Do not tag more than 5 klbs.

2) Pick up and retag PBTD to confirm the depth.

3) Make up the necessary pup joint to space out gun.

4) Make up the tubing hanger c/w landing joint, feed thru all control lines. Pressure test Swagelok fittings to 5000psi for 10 mins.

Record PDHG reading, current and voltage to gauge before cutting the TEC line.

DO NOT wrap control line around tubing BELOW tubing hanger.

5) Reconnect the TR-SCSSV & TEC line.

6) Pressure test TR-SCSSV to 6500psi for 10mins. Bleed down to 3000psi and RIH till hanger is landed.

While pressure testing control lines, drain BOP stack through annulus valve on THS and leave it open.

7) Start making up landing joint and RIH slowly to land the tubing hanger.

Space out landing joint to ensure no tubing collar across the BOP rams

8) Ensure TR-SCSSV c/line pressure remains at 3000 psi and PHDG data is logged on till hanger is landed.

9) Once hanger landed, secure hanger with lock screws and record lock screws stickout measurement.

10) Pressure test hanger body seal to 5000psi for 15mins.

DO NOT rig down the tubing tong at this moment.


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18. TUBING INTEGRITY TEST, INFLOW TEST & SET PACKER

The objective of the section is to test the completion string integrity, perform TR-SCSSV inflow test and set the all production packers. The annulus will also be tested to ensure no leaking on the top packer.


1) Rig up pumping surface equipment.

Install lo-torque valve on pump-in-tee side entry inlet

Break circulation to confirm line up is correct to cement unit

Pressure test line to 5000 psi.

Use seawater for all pressure test.

2) Open lo-torque valve. Dowell to zero stroke counter and record total volume required to pressure up string to set pkr.

Neural to monitor PDHG reading.

Ensure annulus valve is open to monitor any return.

3) Start pressure up string to 1000 psi for 5 mins to test tubing string integrity and test ball sealing. Ensure no return at annulus valve.

4) Dowell to zero stroke counter and ensure chart recorder is engaged.

5) Pressure up string gradually to 3000 psi for 15 mins to fully set AHC single packer.

Ensure no return at annulus valve.

Indication of packer STS should be seen around 1900 psi

6) Bleed off TR-SCSSV control line pressure to 0 psi to close TR-SCSSV.

7) Perform inflow test TR-SCSSV by bleed off tubing pressure above TR-SCSSV to 200 psi - monitor pressure increase for 15 mins.

8) Increase tubing pressure to 3000 psi.

9) Pressure up TR-SCSSV control line pressure to 7500 psi to open TR-SCSSV flapper valve.

10) Continue to pressure up to maximum 4500 psi to open POUV.

DO NOT go beyond 4500 psi. Call town if POUV fail to open.

11) Once POUV is open, continue monitor string pressure for 15 minutes to test packer from below.

12) Bleed off annulus pressure gradually to 0 psi.

13) Follow the following procedures only if the POUV fail to open.

a. Line up test line to annulus. Pressure test line to 250/3000 psi for 5/5 mins.

b. Zero stroke counter on cement unit and pressure up annulus to 3000 psi for 15 mins in 500 psi increment to test pkr from top. Monitor string for return.

c. Bleed off annulus pressure gradually to 0 psi.

14) Rig down pumping surface equipment.

15) Prepare to nipple down BOP.


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19. NIPPLE DOWN BOP & NIPPLE UP CHRISTMAS TREE

The objective of the section is to nipple down the drilling BOP with all barrier tested and in place before start to nipple up the Christmas Tree. Well barrier status prior to BOP removal:

BARRIER TUBING ANNULUS

1ST Barrier Unperforated Casing Top Production Packer

2nd Barrier Back Pressure Valve Tubing Hanger


1) Bleed off TR-SCSSV control line pressure slowly to 0 psi, to close TR-SCSSV.

2) Cut and remove TR-SCSSV control line and PDG TEC line.

3) Make up 3” One Way BPV on rig floor to running tool and set in the tubing hanger profile using dry rod.

4) Proceed to nipple down BOP stack as per rig Standard Operating Procedure.

5) Remove DHCV Exit block and seal ring from the DHCV exit port.

6) Rough cut control line at approx. 6 ft from top of Tubing Head Spool (THS) and remove BPV.

7) Clean the THS and Tubing Hanger and blow dry with compressed air.

8) Thoroughly clean the control line exit port and seal groove.

9) Carefully wrap all control lines around the Tubing Hanger neck one or two wraps.

10) Carefully feed the end of the control line through the open DHCV exit port and pull out on the control line to remove excess.

11) Cut the control line 4” from the exit port. Remove all rough edges from cut off end.

12) Carefully connect the control line to the DHCV Exit Valve.

13) Reinstalled the DHCV Exit Block to the T.

14) Repeat the same procedure for remaining control lines and DHCV block.

15) Placed new 2-9/16” MTM Seal on the top the Tubing Hanger.

16) Place a 2” x 4” soft wood and slowly tap it down with a hammer until it bottoms out the shoulder of the MTM.

17) Apply hydraulic oil on the tubing hanger neck S-Seal and re-install S-Seal.

18) Place ring gasket in the top of the THS groove.

19) Fill THS void area with hydraulic oil.

20) Pick-up, align and level Xmas Tree c/w Adapter above the THS. Xmas Tree will lower down using combination of blocks and winch.

21) Slowly and carefully lower down the Xmas Tree over the Tubing Hanger neck and MTM Seal until the flange sits out on the ring gasket.

22) Tighten the bolting in a crisscross manner pattern using an air winch driven wrench.

23) Locate the two (2) “Void Test” ports on Tubing Head Adapter and inject hydraulic oil until it overflows to the other side.

24) Close the other port and continue pressure up to 5000 psi max. Hold for 15 mins. Bleed off pressure to 0 psi after successful test.


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25) Install 3” TWCV in tubing hanger.

26) Close both wing valves. Ensure the all LMV, UMV and SWAB are open. The PWV and KWV are closed. Fill Xmas Tree bore with water, reinstall tree cap, attach hydraulic test pump and test the Xmas Tree to 500/ 4,500 psi 5/15 mins.

27) Monitor for leakage through 9/16” autoclave ports marked ‘TOP VENT PORT’ and ‘BTM SEAL VENT PORT’ in tubing head adapter for 10 minutes.

28) After successful pressure test, bleed off pressure from tree bore.

29) Bleed off pressure to 0 psi after successful test.

30) Close SWAB valve.

31) Attach the hydraulic hand pump to the Exit Block, pressure up the control line slowly to require pressure and monitor for 15 minutes. Bleed off pressure when tested – ok.

32) Remove the 3” TWCV from the tubing hanger.

33) Skid rig to next well. Prepare to temporary handover well to HUC team for flowline installation as per Attachment 6: Well Handover Form.

20. WELL PERFORATION & CLEAN UP FLOW (OFFLINE)

A safety meeting must be conducted with all concerned prior to the commencement of operations. Schlumberger’s ‘radio safe’ system will be employed so radio silence will not be a requirement throughout the perforation operation.

The objectives of the well clean up program are to safely unload wellbore completion fluid any residual drilling mud and flow well until the produced oil stream is covering annulus area. While flowing, the well deliverability will be monitored using the real-time PDG and Production Test Separator data and surface flow rate estimates from choke calculations.

Prior to the perforation run all the flowline equipment and associated systems must be hooked up and commission by the HUC team and ready for operation. Inform MOPU and confirm that everything is ready to go.

HUC team need to handover back the well to Drilling by filling the Well Handover Form as per Attachment 6.


1) Install a ‘lo-torq’ valve (LTV) at Production Wing Valve (PWV), Kill Wing Valve (KWV) and Annulus Valve (AV).

2) Connect line from cementing unit to KWV. P/test line using drill water against the KWV to 500/ 5000 psi for 2/5 mins respectively. Bleed off pressure to 0 psi after successful test.

3) Before starting the perforation sequence, ensure

LMV, UMV, Swab Valve (SV) and PWV (directly to Production choke) are open and a fusible lock-open cap are installed on the UMW actuator.

Production Choke and Annulus Valve are closed.

Neural to set PDG reading with sampling rate set at 1 second.

Record PDG reading prior to perforation.

4) R/U slickline with pumping tee on & test lubricator to 500/3000 psi for 5 mins.

5) Run BO shifting toolstring to open SSD @ 750 m.

6) Circulate N2 through tubing and SSD. Take return from annulus on Tote tank. Measure vol return. (Fluid level inside string approx. 700 m).


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7) Hold pressure approx. 600 psi (TBC onsite) to avoid U-tube.

8) RIH BO shifting toolstring. Close SSD @ 750 m.

9) R/Down S/line.

10) PJSM – Hazard involved during well perforation / firing head activation.

11) Close Annulus Valve and monitor pressure inside annulus.

Pressure inside annulus should not increase when sending firing sequence. If it increases, possible the packer is not set correctly and firing command should be aborted.

12) Ready to send firing command as per below:

A trial pulses need to be exercised with the cement/pump operator to familiarize the operator on the proper pumping sequence, once satisfied 10 min are needed for the pressure plateau to stabilize before sending the actual firing command.

Note: eFire will be programmed with 10 minute delay time. Plateau at point 3, 6, 9 and 12 will be 12 - 30 second each pulse. Follow TCP Specialist instruction during sending eFire firing command.

Note: In case of the event of facing problem, proceed with abort command to abort the firing head by apply 1000 psi inside the string which will against the trigger pressure and wait for 2 minute. Once the problem solved, repeat back the firing command step. (To be advised by Schlumberger TCP Supervisor).

13) Bleed off pressure to 0 psi and monitor gun to fire after 10 minutes of delay time.

14) After getting the indication of perforation, record SITHP and SIBHP reading every 1 min. Observe the well for min 15 minutes or until stable reading.

15) Open well for clean up using initial choke setting of 12/64” to begin flow the well for 2-4 hrs and let the well stabilize (as per Well Start Up Procedure – Document No WD1-PR-O-0069).

Monitor FTHP, FBHP, FTHT and FBHT every 1 min.

Monitor production rate at separator every 15 mins.

16) Bean up the well gradually in steps of 4/64” increments until 32/64”, allowing for pressure to build up and level at each time. Maintain flow at each step between 2-4 hrs.

Record the choke sizes at each change


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Monitor FTHP, FBHP, FTHT and FBHT every 5 minutes for the first hour, and every 10 minutes thereafter.

Monitor production rate at separator every 30 mins.

Monitor CHP every 30 mins. Ensure CHP is below 1500 psi during flowback.

17) In general, the well is deemed to be cleaned when the following criteria are observed:

Fluctuation in FTHP is less than 10 psi over 1 hr at expected rate

Relatively constant BS&W with percentage of completion brine is less than 5%

No solid observed from fluid sample

Well is able to flow naturally at minimum FTHP required by surface facilities.

18) Prepare to handover well to MOPU Operation as per Well Handover Document (Document No WD1-9100-00-HU-PRO-0005-REV 1).


PML-PR-D-0329

Rev 2

21. ATTACHMENT

Attachment 01: Well Completion Authorization

Attachment 02: Pit Management

Attachment 03: BOP Configuration

Attachment 04: Wellbore Clean Out BHA Diagram

Attachment 05: TCP BHA diagram

Attachment 06: Well Handover Form

Attachment 07: Tubular Data Sheet

Attachment 08: HAL Upper Completion DOS

Attachment 09: NEURAL PDG Installation Procedure

Attachment 10: SLB TCP Firing Procedure

Attachment 11: GRE Field Procedure

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